CN106769688A - Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition - Google Patents
Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition Download PDFInfo
- Publication number
- CN106769688A CN106769688A CN201710004832.4A CN201710004832A CN106769688A CN 106769688 A CN106769688 A CN 106769688A CN 201710004832 A CN201710004832 A CN 201710004832A CN 106769688 A CN106769688 A CN 106769688A
- Authority
- CN
- China
- Prior art keywords
- pressure
- diffusion coefficient
- diffusion
- natural gas
- temperature
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000009792 diffusion process Methods 0.000 title claims abstract description 123
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 title claims abstract description 102
- 239000003345 natural gas Substances 0.000 title claims abstract description 49
- 238000000034 method Methods 0.000 title claims abstract description 32
- 239000007789 gas Substances 0.000 claims abstract description 40
- 239000002734 clay mineral Substances 0.000 claims abstract description 27
- 239000011148 porous material Substances 0.000 claims abstract description 27
- 239000011435 rock Substances 0.000 claims abstract description 26
- 238000011160 research Methods 0.000 claims abstract description 18
- 230000004913 activation Effects 0.000 claims abstract description 15
- 239000008398 formation water Substances 0.000 claims abstract description 6
- 238000012216 screening Methods 0.000 claims abstract description 4
- 239000004576 sand Substances 0.000 claims description 24
- 230000035699 permeability Effects 0.000 claims description 9
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 8
- 238000002474 experimental method Methods 0.000 claims description 4
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 claims description 4
- 229910052753 mercury Inorganic materials 0.000 claims description 4
- 102000003712 Complement factor B Human genes 0.000 claims description 2
- 108090000056 Complement factor B Proteins 0.000 claims description 2
- 230000000704 physical effect Effects 0.000 claims description 2
- 238000009738 saturating Methods 0.000 abstract 1
- 230000008859 change Effects 0.000 description 4
- 238000011161 development Methods 0.000 description 2
- 238000002050 diffraction method Methods 0.000 description 2
- 238000012360 testing method Methods 0.000 description 2
- 241001269238 Data Species 0.000 description 1
- 230000009286 beneficial effect Effects 0.000 description 1
- 238000004364 calculation method Methods 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000011156 evaluation Methods 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 230000004907 flux Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000005065 mining Methods 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000009418 renovation Methods 0.000 description 1
- 238000004088 simulation Methods 0.000 description 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N13/00—Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N13/00—Investigating surface or boundary effects, e.g. wetting power; Investigating diffusion effects; Analysing materials by determining surface, boundary, or diffusion effects
- G01N2013/003—Diffusion; diffusivity between liquids
Landscapes
- Physics & Mathematics (AREA)
- Health & Medical Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Investigation Of Foundation Soil And Reinforcement Of Foundation Soil By Compacting Or Drainage (AREA)
Abstract
The invention provides a method for predicting a diffusion coefficient of natural gas in tight sandstone under geological conditions. The method comprises the following steps: collecting rock samples, screening compact sandstone samples, and saturating formation water with the screened samples; carrying out natural gas diffusion coefficient experimental determination under different temperature and pressure conditions according to the temperature and pressure variation range of the stratum of the research area and the natural gas composition; establishing a kinetic model of natural gas diffusion coefficient and temperature, and determining the ratio of diffusion activation energy to a gas constant; establishing an exponential model of natural gas diffusion coefficient and pressure, and determining a diffusion pressure factor; establishing a linear model of the ratio of the clay mineral content, the diffusion activation energy and the gas constant; establishing a linear model of the reciprocal of the median radius of the pore throat and a diffusion pressure factor; establishing a diffusion coefficient multi-factor model; and predicting the diffusion coefficients of different rocks in the research area under different temperature and pressure conditions by using a diffusion coefficient multi-factor model.
Description
Technical field
It is to be related under the conditions of a kind of prediction geology day in tight sand specifically the present invention relates to petroleum exploration field
The method of right gas diffusion coefficient.
Background technology
Compact sandstone gas have turned into the major fields of global Unconventional gas exploration, and there has been more than 70 basin in the current whole world
It was found that or speculate development compact sandstone gas, stock number is about 209.6 × 1012m3, it is distributed mainly on North America, Latin America and Asia-Pacific
Area.The U.S. is that compact sandstone gas develop earliest area, and compact sandstone gas yield is about 1690 × 10 within 20118m3, account for the U.S.
26% (EIA, 2012) of natural gas total output.China should recently as the progress and scale of massive hydraulic fracturing renovation technique
With compact sandstone gas exploration and development makes substantial progress.According to newest estimation, Chinese compact sandstone gas mining resources amount about (9~
13)×1012m3, compact sandstone gas yield is about 256 × 10 within 20118m3, 25% or so (Zou for accounting for national natural gas total output
Could wait, 2013).Because reservoir has the strong feature of low porosity and low permeability, anisotropism, Gas diffusion is formed in compact sandstone gas
During played important function, but at present still without diffusion coefficient of natural gas in tight sand under the conditions of prediction geology
Effective ways, so as to Gas diffusion amount has very big difference in causing the tight sand for calculating.
Diffusion coefficient of natural gas represents diffusivity of the natural gas in tight sand in tight sand, refers to concentration gradient
Diffusion flux during for a unit, unit is cm2/s.Diffusion coefficient of natural gas can by theoretical calculation and measuring come
Obtain, but due to the complexity of subsurface rock porous media, determine diffusion coefficient of the natural gas in rock and be only research ground
The fundamental way of lower Gas diffusion effect.Domestic and international some scholars are directed to measuring of the natural gas in diffusion coefficient of rock
Method is done a lot of work.The former Russian scholar Antonov diffusion coefficients of the lighter hydrocarbons in sedimentary rock in experimental determination first,
Xiao is without the diffusion coefficient for so waiting successfully natural gas in rock under experimental determination normal temperature and pressure conditionses at home.Hao Shisheng etc.
Experimental technique is improved, the diffusion coefficient of the methane in saturation water rock under different temperatures and pressure condition is determined.
Krooss etc. proposes diffusion coefficient of natural gas and determines new method, tests and satisfy under normal temperature and pressure conditionses natural gas in waterstone
Diffusion parameter.Li Zhisheng etc. have developed the apparatus and method that diffusion coefficient of natural gas is determined in rock under high-temperature and high-pressure conditions.
Liu Guangdi, pair wide and Zhang Yun peak etc. analyze temperature, pressure, porosity pair respectively on the basis of measuring diffusion coefficient
The influence of diffusion coefficient.
Diffusion coefficient of natural gas in tight sand, and root can be realized determining under lab under high-temperature and high-pressure conditions at present
According to experimental data, on the premise of assuming that other geologic(al) factors are constant, determine a kind of specific geologic(al) factor to diffusion coefficient
Influence, so as to establish the unifactor model of diffusion coefficient and temperature, pressure and porosity, but not yet proposition can be pre- at present
The method for surveying the diffusion coefficient various geologic(al) factors change simultaneously in the case that.
The content of the invention
It is an object of the present invention to provide a kind of fine and close sand predicted in the case of the change simultaneously of various geologic(al) factors
The method of diffusion coefficient of natural gas in rock.At least to solve that in correlation technique the feelings that various geologic(al) factors change cannot be determined simultaneously
The technical problem of period of history Gas diffusion amount cannot be computed correctly caused by diffusion coefficient of natural gas under condition.
It is up to above-mentioned purpose, on the one hand, expand the invention provides natural gas in tight sand under the conditions of one kind prediction geology
The method for dissipating coefficient, wherein, methods described comprises the following steps：
(1) rock sample is gathered, tight sand sample, and the sample saturation stratum water that will be selected is screened；
(2) temperature and pressure excursion according to research area stratum and natural gas composition, carry out different temperatures and pressure
Under the conditions of diffusion coefficient of natural gas measuring；
(3) kinetic model of diffusion coefficient of natural gas and temperature is set up, the ratio of Diffusion Activation Energy and gas constant is determined
Value；
(4) exponential model of diffusion coefficient of natural gas and pressure is set up, the diffusion pressure factor is determined；
(5) linear model of clay mineral content and Diffusion Activation Energy and gas constant ratio is set up；
(6) the pore throat median radius linear model with the diffusion pressure factor reciprocal is set up；
(7) diffusion coefficient Multiple-Factor Model is set up；
(8) diffusion coefficient Multiple-Factor Model, diffusion system of the forecasting research area difference rock under different Temperature-pressure Conditions are utilized
Number.
According to some specific embodiments of the invention, wherein, step (1) is collection research area's tectonic setting and depositional environment
The widely distributed rock sample of similar and physical properties of rock.
According to some specific embodiments of the invention, wherein, step (1) be according to the porosity of collection sample, permeability,
Principle that pore throat median radius and clay mineral content are distributed from low to high gathers rock sample.
According to some specific embodiments of the invention, wherein, step (1) is that screening pore throat median radius and clay mineral contain
Amount tight sand sample from high to low；
According to some specific embodiments of the invention, wherein, step (1) is to filter out pore throat median radius between 0 to 1 μ
M, clay mineral content is between 0 to 100%, the sample being distributed from high to low.
According to some specific embodiments of the invention, wherein, step (1) be by porosity, permeability, high-pressure mercury and
X diffraction experiments determine to screen pore throat median radius and clay mineral content tight sand sample from high to low.
According to some specific embodiments of the invention, wherein, the sample size that step (1) is screened must not be less than 4 pieces.
According to some specific embodiments of the invention, wherein, step (1) is by SY/T 5336-2006, GB/T
21650.1-2008 and SY/T 5163-2010 standards carry out porosity, permeability, pore throat median radius and clay mineral content
Measure.
According to some specific embodiments of the invention, wherein, step (1) is the formation water salinity value according to research area,
The sample saturation stratum water that will be filtered out.
Wherein it is understood that the formation water salinity for using will keep one with the size of research area's formation water salinity
Cause.
According to some specific embodiments of the invention, wherein, the day under different temperatures and pressure condition is carried out in step (2)
Right gas diffusion coefficient measuring is that the minimum temperature that is experienced from research area's rock and pressure accomplish maximum temperature and pressure, temperature
Degree measures at least 4 temperature spots at regular intervals, and 4 pressure spots are at least measured under each temperature spot.
According to some specific embodiments of the invention, wherein, diffusion coefficient of natural gas is determined and presses SY/T in step (2)
6129-1995 standards are carried out.
Wherein it is understood that the gas component that diffusion coefficient measuring is used will be with research area's gas component
It is consistent
According to some specific embodiments of the invention, wherein, the kinetic simulation of step (3) diffusion coefficient of natural gas and temperature
Type isWherein D- diffusion coefficients (cm2/ s), Ea- activation energy (cal/mol), R- gas constants (1.987cal
mol-1·K-1), T- temperature (K), A-Pre-exponential factor, so that it is determined that the numerical value of Diffusion Activation Energy and gas constant ratio Ea/RT.
According to some specific embodiments of the invention, wherein, step (3) is to draw the diffusion coefficient under same pressure condition
The cross plot of D and temperature T, sets up the kinetic model of diffusion coefficient of natural gas and temperature.
According to some specific embodiments of the invention, wherein, the exponential model of step (4) diffusion coefficient of natural gas and pressure
It is D=AeBP, wherein D- diffusion coefficients (cm2/ s), A- pre-exponential factors (cm2/ s), B- press factors, P- pressure (MPa), so that
Determine the numerical value of press factors B.
According to some specific embodiments of the invention, wherein, step (4) step (4) are under the conditions of drawing same temperature
Diffusion coefficient D and the cross plot of pressure P, set up the exponential model of diffusion coefficient of natural gas and pressure.
According to some specific embodiments of the invention, wherein, step (5) is to set up clay mineral content and Diffusion Activation Energy
It is Ea/R=a with the linear model of gas constant ratio1C+b1, wherein Ea- activation energy (cal/mol), R- gas constants
(1.987cal·mol-1·K-1), C- clay mineral contents (%)；
According to some specific embodiments of the invention, wherein, step (6) is to set up pore throat median radius inverse to be pressed with diffusion
The linear model of the power factor is B=a2/r+b2, wherein B- press factors, r- pore throats median radius (nm)；
According to some specific embodiments of the invention, wherein, step (7) is to set up diffusion coefficient Multiple-Factor Model for D=
Ae-(a1C+b1)/T-(a2/r+b2)P, wherein D- diffusion coefficients (cm2/ s), A- pre-exponential factors, C- clay mineral contents (%), T- temperature
(DEG C), r- pore throats median radius (nm), P- pressure (MPa).
In sum, the invention provides the side of diffusion coefficient of natural gas in tight sand under the conditions of a kind of prediction geology
Method.The method of the present invention has the following advantages that：
By the method for the present invention, solving in the case of cannot determine in the prior art the change simultaneously of various geologic(al) factors
Diffusion coefficient of natural gas caused by cannot correct evaluation history period Gas diffusion amount technical problem, realize one
Rock is provided in the diffusion coefficient of natural gas prediction of different periods of history for period of history Gas diffusion amount is calculated from different places
Call parameter.
Brief description of the drawings
Fig. 1 be according to embodiments of the present invention 1 prediction geology under the conditions of in tight sand diffusion coefficient of natural gas work
Method flow diagram；
Fig. 2 is the cross plot of the diffusion coefficient with temperature of according to embodiments of the present invention 1 sample 1, determines each sample
The ratio Ea/R of average diffusion activation energy and gas constant R；
Fig. 3 is the cross plot of the diffusion coefficient with pressure of according to embodiments of the present invention 1 sample 1, determines each sample
Diffusion pressure factor B；
Fig. 4 is according to embodiments of the present invention 1 clay mineral content C and every piece of sample average Ea/R cross plot, determines mould
A in type1And b1；
Fig. 5 is according to embodiments of the present invention 1 pore throat median radius inverse 1/r and every piece of sample average B cross plot, it is determined that
A in model2And b2。
Specific embodiment
Implementation process of the invention and the beneficial effect for producing are described in detail below by way of specific embodiment, it is intended to which help is read
Reader more fully understands essence of the invention and feature, not as to this case can practical range restriction.
Embodiment 1
In embodiments of the present invention 1, there is provided Gas diffusion system in tight sand under the conditions of one kind prediction geology
Several method, as shown in figure 1, comprising the following steps：
Step S101：Collection research area's tectonic setting rock sample widely distributed with transitivity similar with depositional environment；
Step S102：Porosity, permeability, high-pressure mercury and X diffraction analysis are carried out to sample, pore throat median radius are screened
With clay mineral content tight sand sample from high to low；
Step S103：It is determined that the highest, minimum that the formation water salinity in research area, natural gas composition and rock are experienced
Historical temperature and pressure；
Step S104：The sample saturation stratum water that to filter out, carry out same temperature, pressure from low to high and same pressure
Power, temperature from low to high, the diffusion coefficients under the conditions of the different temperatures and pressure series of fixed intervals；
Step S105：Set up the index mould of the kinetic model of diffusion coefficient of natural gas and temperature, diffusion coefficient and pressure
Type, it is determined that average Ea/R and average B；
Step S106：Set up the linear model of clay mineral content C and average Ea/R, pore throat median radius inverse 1/r with
The linear model of average B, determines a in diffusion coefficient Multiple-Factor Model1、b1, a2、b2；
Step S107：According to diffusion coefficient experimental data and known T, P, C, r, a1、b1, a2、b2, determine diffusion coefficient
Pre-exponential factor A in Multiple-Factor Model；
Step S108：Set up diffusion coefficient Multiple-Factor Model D=Ae-(a1C+b1)/T-(a2/r+b2)P, carry out under geological conditions
Diffusion coefficient is predicted.
By the above method of present embodiment to Gas diffusion system in Upper Paleozoic in Ordos Basin tight sand
Number is predicted.
Specifically, 58 pieces of Upper Paleozoic in Ordos Basin Sulige area tight sand sample is acquired, by SY/T
5336-2006, GB/T 21650.1-2008 and SY/T 5163-2010 standards have carried out porosity, permeability, high pressure to sample
Pressure mercury and X diffraction analysis, screening pore throat median radius and clay mineral content 5 pieces of tight sand sample from high to low.
Table 1：The basic parameter test data of experiment of the 5 pieces of samples for filtering out
According to oil field data, the average salinity of Sulige area Upper Palaeozoic Strata water is determined for 43.12g/L, naturally
Gas composition is mainly methane gas, and the temperature that rock is experienced is 30~120 DEG C, and pressure is 8-32MPa.
By 5 blocks of sample saturation stratum water, it is 30 DEG C to enter trip temperature by SY/T 6129-1995 standards, pressure is respectively 8,
16、24、32MPa；Temperature is 60 DEG C, pressure is respectively 8,16,24,32MPa, temperature be 90 DEG C, pressure is respectively 8,16,24,
32MPa, temperature are 120 DEG C, pressure is respectively 8,16,24, the diffusion coefficient of natural gas under the conditions of 32MPa determines.
Table 2：5 pieces of diffusion coefficient experimental datas of sample
According to experimental data, the cross plot of diffusion coefficient D of the every piece of sample under same pressure condition and temperature T is done, seen
Shown in Fig. 2, the kinetic model of diffusion coefficient and temperature is set up, determine every piece of average Ea/R of sample.
According to experimental data, the cross plot of diffusion coefficient D of the every piece of sample under the conditions of same temperature and pressure P is done, seen
Shown in Fig. 3, the exponential model of diffusion coefficient and pressure is set up, determine every piece of average B of sample.
The cross plot of clay mineral content C and average Ea/R is done, the linear model of Ea/R and C is set up, as shown in Figure 4, really
Determine a in Multiple-Factor Model1=2.0903, b1=43.244.
The cross plot of pore throat median radius inverse 1/r and average B is done, the linear model of B and 1/r is set up, as shown in Figure 5,
Determine a in Multiple-Factor Model2=0.5029, b2=0.0174.
According to diffusion coefficient experimental data and known T, P, c, r, a1、b1, a2、b2, determine diffusion coefficient Multiple-Factor Model
In pre-exponential factor A=4.1619 × 10-5。
Finally set up diffusion coefficient Multiple-Factor Model D=4.1619 × 10-5e-(2.0903c+43.244)/T-(0.5029/r+0.0174)P,
Wherein D- diffusion coefficients (cm2/ s), T- temperature (DEG C), P- pressure (MPa), C- clay mineral contents (%), r- pore throats intermediate value half
Footpath (nm).
Pore throat median radius, clay mineral content and residing temperature, pressure condition according to research area's tight sand, profit
The diffusion coefficient Multiple-Factor Model set up in aforementioned manners, you can in carrying out any temperature, pressure, clay mineral content and pore throat
Diffusion coefficient prediction under the conditions of value radius, so as to provide call parameter for the Gas diffusion amount of period of history is calculated.
Claims (10)
1. a kind of method for predicting diffusion coefficient of natural gas in tight sand under the conditions of geology, wherein, methods described includes as follows
Step：
(1) rock sample is gathered, tight sand sample, and the sample saturation stratum water that will be selected is screened；
(2) temperature and pressure excursion according to research area stratum and natural gas composition, carry out different temperatures and pressure condition
Under diffusion coefficient of natural gas measuring；
(3) kinetic model of diffusion coefficient of natural gas and temperature is set up, the ratio of Diffusion Activation Energy and gas constant is determined；
(4) exponential model of diffusion coefficient of natural gas and pressure is set up, the diffusion pressure factor is determined；
(5) linear model of clay mineral content and Diffusion Activation Energy and gas constant ratio is set up；
(6) the pore throat median radius linear model with the diffusion pressure factor reciprocal is set up；
(7) diffusion coefficient Multiple-Factor Model is set up；
(8) diffusion coefficient Multiple-Factor Model, diffusion coefficient of the forecasting research area difference rock under different Temperature-pressure Conditions are utilized.
2. method according to claim 1, wherein, step (1) is that collection research area's tectonic setting is similar with depositional environment
And the widely distributed rock sample of physical properties of rock；Porosity, permeability, pore throat intermediate value half wherein preferably according to collection sample
Principle that footpath and clay mineral content are distributed from low to high gathers rock sample.
3. method according to claim 1, wherein, step (1) be screening pore throat median radius and clay mineral content from
High to Low tight sand sample；Pore throat median radius preferably wherein are filtered out between 0 to 1 μm, and clay mineral content is between 0
To 100%, the sample being distributed from high to low；It is preferred that sample size must not be less than 4 pieces；It is also preferable that by porosity, permeability,
High-pressure mercury and X diffraction experiments determine to screen pore throat median radius and clay mineral content tight sand sample from high to low
Product；Further preferably step (1) is carried out by SY/T 5336-2006, GB/T 21650.1-2008 and SY/T 5163-2010 standards
The measure of porosity, permeability, pore throat median radius and clay mineral content.
4. method according to claim 1, wherein, step (1) is the formation water salinity value according to research area, will be screened
The sample saturation stratum water for going out.
5. method according to claim 1, wherein, the natural gas under different temperatures and pressure condition is carried out in step (2)
Diffusion coefficient measuring is to accomplish maximum temperature and pressure from the minimum temperature that is experienced of research area's rock and pressure, and temperature is pressed
Certain intervals measure at least 4 temperature spots, and 4 pressure spots are at least measured under each temperature spot；Wherein preferred Gas diffusion
Coefficient determination is carried out by SY/T 6129-1995 standards.
6. method according to claim 1, wherein, step (3) diffusion coefficient of natural gas is with the kinetic model of temperatureWherein D- diffusion coefficients (cm2/ s), Ea- activation energy (cal/mol), R- gas constants (1.987calmol-1·K-1), T- temperature (K), A-Pre-exponential factor, so that it is determined that the numerical value of Diffusion Activation Energy and gas constant ratio Ea/RT；It is preferred that
Step (3) is to draw the cross plot of the diffusion coefficient D under same pressure condition and temperature T, sets up diffusion coefficient of natural gas with temperature
The kinetic model of degree.
7. method according to claim 1, wherein, step (4) diffusion coefficient of natural gas is D=with the exponential model of pressure
AeBP, wherein D- diffusion coefficients (cm2/ s), A- pre-exponential factors (cm2/ s), B- press factors, P- pressure (MPa), so that it is determined that pressure
The numerical value of power factor B；Preferred steps (4) are to draw the cross plot of the diffusion coefficient D under the conditions of same temperature and pressure P, are set up
The exponential model of diffusion coefficient of natural gas and pressure.
8. method according to claim 1, wherein, step (5) is to set up clay mineral content and Diffusion Activation Energy and gas
The linear model of body constant ra-tio is Ea/R=a1C+b1, wherein Ea- activation energy (cal/mol), R- gas constants
(1.987cal·mol-1·K-1), C- clay mineral contents (%).
9. method according to claim 1, wherein, step (6) be set up pore throat median radius it is reciprocal with diffusion pressure because
The linear model of son is B=a2/r+b2, wherein B- press factors, r- pore throats median radius (nm).
10. method according to claim 1, wherein, step (7) is to set up diffusion coefficient Multiple-Factor Model：D=Ae-(a1C+b1)/T-(a2/r+b2)P, wherein D- diffusion coefficients (cm2/ s), A- pre-exponential factors, C- clay mineral contents (%), T- temperature
(DEG C), r- pore throats median radius (nm), P- pressure (MPa).
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710004832.4A CN106769688B (en) | 2017-01-04 | 2017-01-04 | Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710004832.4A CN106769688B (en) | 2017-01-04 | 2017-01-04 | Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN106769688A true CN106769688A (en) | 2017-05-31 |
| CN106769688B CN106769688B (en) | 2019-08-06 |
Family
ID=58949868
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710004832.4A Active CN106769688B (en) | 2017-01-04 | 2017-01-04 | Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN106769688B (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107389519A (en) * | 2017-06-06 | 2017-11-24 | 湖北工业大学 | A kind of characteristic parameter Forecasting Methodology of soil-water characteristic curve two based on mercury injection method |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103267721A (en) * | 2013-05-03 | 2013-08-28 | 中国石油天然气集团公司 | Method for evaluating water containing characteristic and occurrence state of compact sandstone storage layer aperture |
| CN105628559A (en) * | 2014-10-30 | 2016-06-01 | 中国石油天然气股份有限公司 | Shale gas diffusion capacity detection method, device and system |
-
2017
- 2017-01-04 CN CN201710004832.4A patent/CN106769688B/en active Active
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN103267721A (en) * | 2013-05-03 | 2013-08-28 | 中国石油天然气集团公司 | Method for evaluating water containing characteristic and occurrence state of compact sandstone storage layer aperture |
| CN105628559A (en) * | 2014-10-30 | 2016-06-01 | 中国石油天然气股份有限公司 | Shale gas diffusion capacity detection method, device and system |
Non-Patent Citations (2)
| Title |
|---|
| 娄洪,罗鹏,薛盼,杨威: "《天然气扩散系数影响因素的定量模拟研究》", 《内蒙古石油化工》 * |
| 柳广弟，赵忠英，孙明亮，李剑，胡国艺，王晓波: "《天然气在岩石中扩散系数的新认识》", 《石油勘探与开发》 * |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN107389519A (en) * | 2017-06-06 | 2017-11-24 | 湖北工业大学 | A kind of characteristic parameter Forecasting Methodology of soil-water characteristic curve two based on mercury injection method |
Also Published As
| Publication number | Publication date |
|---|---|
| CN106769688B (en) | 2019-08-06 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Ren et al. | Formation mechanism of the Upper Triassic Yanchang Formation tight sandstone reservoir in Ordos Basin—Take Chang 6 reservoir in Jiyuan oil field as an example | |
| CA3053660C (en) | Prediction method for shale oil and gas sweet spot region, computer device and computer readable storage medium | |
| Cui et al. | Prediction of diagenetic facies using well logs–A case study from the upper Triassic Yanchang Formation, Ordos Basin, China | |
| Chalmers et al. | Lower Cretaceous gas shales in northeastern British Columbia, Part II: evaluation of regional potential gas resources | |
| Zou et al. | Tight gas sandstone reservoirs in China: characteristics and recognition criteria | |
| Song et al. | Impact of permeability heterogeneity on production characteristics in water-bearing tight gas reservoirs with threshold pressure gradient | |
| CN104564041B (en) | Hyposmosis clastic reservoir rock efficiency evaluation method based on exploitation permeability limits | |
| Wang et al. | Comparative studies of microscopic pore throat characteristics of unconventional super-low permeability sandstone reservoirs: Examples of Chang 6 and Chang 8 reservoirs of Yanchang Formation in Ordos Basin, China | |
| Zhang et al. | Pressure–dependent fracture permeability of marine shales in the Northeast Yunnan area, Southern China | |
| Liu et al. | Reservoir characterization of Chang 7 member shale: a case study of lacustrine shale in the Yanchang Formation, Ordos Basin, China | |
| Zhao et al. | Physical property and hydrocarbon enrichment characteristics of tight oil reservoir in Chang 7 division of Yanchang Formation, Xin'anbian oilfield, Ordos Basin, China | |
| CN106223941A (en) | Shale gas reservoir organic porosity based on well-log information determines method | |
| Liu et al. | Pore structure and physical properties of sandy conglomerate reservoirs in the Xujiaweizi depression, northern Songliao Basin, China | |
| Pang et al. | Characteristics and classification of paleozoic tight reservoirs in the central uplift of the South Yellow Sea Basin | |
| YANG et al. | Controlling effects of tight reservoir micropore structures on seepage ability: A case study of the upper Paleozoic of the Eastern Ordos Basin, China | |
| CN112784404B (en) | Method for calculating saturation of bonded water in sandstone based on conventional logging data | |
| Xizhe et al. | Main flow channel index in porous sand reservoirs and its application | |
| Shi et al. | Pore structure characteristics and evaluation of carbonate reservoir: a case study of the lower carboniferous in the marsel exploration area, Chu-Sarysu basin | |
| CN106769688B (en) | Method for predicting diffusion coefficient of natural gas in tight sandstone under geological condition | |
| Smith et al. | Relative permeability of Williston Basin CO2 storage targets | |
| CN105888656B (en) | Method for quantitatively evaluating hydraulic permeability under pressure of natural microcrack development tight reservoir | |
| Guo et al. | Characterization of micropore structure of a middle to deep clastic reservoir: The oligocene reservoir in the Nanpu Sag, Bohai Bay Basin, China | |
| CN103926631B (en) | A kind of method determining the sedimentary basin Hydrocarbon Formation Reservoirs lowest limit | |
| Ma et al. | A Preliminary Experimental and Numerical Study on the Applicability of Liquid CO2 Fracturing in Sparse Sandstone | |
| Zhong et al. | Effect of chemical clogging on the permeability of weakly consolidated sandstone due to reinjection at different temperatures |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |